U.S. patent application number 10/215634 was filed with the patent office on 2004-02-12 for one cone bit with interchangeable cutting structures, a box-end connection, and integral sensory devices.
Invention is credited to Moran, David P., Witman, George B. IV.
Application Number | 20040026124 10/215634 |
Document ID | / |
Family ID | 22803769 |
Filed Date | 2004-02-12 |
United States Patent
Application |
20040026124 |
Kind Code |
A1 |
Moran, David P. ; et
al. |
February 12, 2004 |
One cone bit with interchangeable cutting structures, a box-end
connection, and integral sensory devices
Abstract
A drill bit, comprising a bit body, a sensor disposed in the bit
body, a single journal removably mounted to the bit body, and a
roller cone rotatably mounted to the single journal.
Inventors: |
Moran, David P.; (The
Woodlands, TX) ; Witman, George B. IV; (Sugarland,
TX) |
Correspondence
Address: |
Rosenthal & Osha L.L.P.
1221 McKinney, Suite 2800
Houston
TX
77010
US
|
Family ID: |
22803769 |
Appl. No.: |
10/215634 |
Filed: |
August 9, 2002 |
Current U.S.
Class: |
175/40 ;
175/336 |
Current CPC
Class: |
E21B 10/20 20130101;
E21B 10/22 20130101; E21B 47/01 20130101 |
Class at
Publication: |
175/40 ;
175/336 |
International
Class: |
E21B 047/00; E21B
010/14 |
Claims
What is claimed is:
1. A drill bit, comprising: a bit body adapted to be coupled to a
drill string; a sensor disposed in the bit body; a single journal
removably mounted to the bit body; and a roller cone rotatably
mounted to the single journal.
2. The drill bit of claim 1, further comprising a short-hop
telemetry transmission device adapted to transmit data from the
sensor to a measurement-while-drilling device located above the
drill bit on the drill string.
3. The drill bit of claim 1, wherein the sensor comprises a
resistivity sensor.
4. The drill bit of claim 1, further comprising a box-end
connection on an end of the bit body opposite from the removable
journal and adapted to connect the drill bit to the drill
string.
5. The drill bit of claim 4, wherein the sensor comprises a density
logging sensor.
6. The drill bit of claim 4, wherein the sensor comprises a neutron
logging sensor.
7. The drill bit of claim 4, wherein the drill bit is adapted to be
paired with a rotary steerable system.
8. The drill bit of claim 4, wherein the drill bit is adapted to be
paired with a drive device.
9. The drill bit of claim 1, further comprising a temperature
sensor mounted in the single journal.
10. A bit body, comprising: a box-end connection located on one end
of the bit body and adapted to connect the bit body to a drill
string; a journal connection located at an opposite end from the
box-end connection and adapted to receive a removably mounted
journal; and a sensor mounted in the bit body.
11. The bit body of claim 10, wherein the sensor comprises a
density logging sensor.
12. The bit body of claim 10, wherein the sensor comprises a
neutron logging sensor.
13. A drill bit, comprising: a bit body adapted to be coupled to a
drill string; a single journal removably mounted to the bit body; a
temperature sensor disposed in the single journal; and a roller
cone rotatably mounted on the single journal.
14. The drill bit of claim 13, further comprising a sensor disposed
in the bit body.
15. The drill bit of claim 14, wherein the sensor is a density
logging sensor.
16. The drill bit of claim 14, wherein the sensor is a neutron
logging sensor.
17. A drill bit, comprising: a bit body; at least one sensor
disposed in the bit body; a short-hop telemetry transmitter
disposed in the bit body; a box end connection adapted to connect
the bit body to a rotary steerable system; a single journal
removably mounted to the bit body; and a roller cone rotatably
mounted to the single journal.
18. The drill bit of claim 17, wherein the at least one sensor
comprises a density logging sensor.
19. The drill bit of claim 17, wherein the at least on sensor
comprises a neutron logging sensor.
20. A drill bit, comprising: a bit body; a box-end on one end of
the bit body adapted to connect the bit body to a drill string; and
a sensor disposed in the bit body.
21. The drill bit of claim 20, wherein the sensor is a density
logging sensor.
22. The drill bit of claim 20, wherein the sensor is a neutron
logging sensor.
Description
BACKGROUND OF INVENTION
[0001] 1. Field of the Invention
[0002] The invention relates generally to single roller cone drill
bits for drilling boreholes in earth formations. More specifically,
the invention relates to a single cone bit with interchangeable
cutting structures, a box-end connection, and integral sensory
devices for evaluation of the formation and bit health.
[0003] 2. Background Art
[0004] One aspect of drilling technology relates to roller cone
drill bits are used to drill boreholes in earth formations. The
most common type of roller cone drill bit is a three-cone bit, with
three roller cones attached at the end of the drill bit. When
drilling smaller boreholes with smaller bits, the radial bearings
in three-cone drill bits become too small to support the weight on
the bit that is required to attain the desired rate of penetration.
In those cases, a single cone drill bit is desirable. A single cone
drill bit has a larger roller cone than the roller cones on a
similarly sized three cone bit. As a result, a single cone bit has
bearings that are significantly larger that those on a three cone
bit with the same drill diameter.
[0005] FIG. 1A shows a prior art single cone drill bit. The single
cone bit 1 includes one roller cone 4 rotatably attached to a bit
body 16 such that the cone's drill diameter is concentric with the
axis of rotation 6 of the bit 1. The roller cone 4 has a
hemispherical shape and typically drills out a bowl shaped bottom
hole geometry. The drill bit 1 includes a threaded connection 14
that enables the drill bit 1 to be connected to a drill string (not
shown). The male connection shown in FIG. 1A is also called a "pin"
connection. A typical single cone bit is disclosed in U.S. Pat. No.
6,167,975, issued to Estes.
[0006] FIG. 1B shows a cross section of a prior art drill bit 1
drilling a bore hole 3 in an earth formation 2. The roller cone 4
is rotatably mounted on a journal 5 that is connected to the bit
body 16.
[0007] Another aspect of drilling technology involves formation
evaluation using sensors that detect the properties of the
formation, such as resistivity, porosity, and bulk density.
Formation evaluation allows a well operator to know the properties
of the formation at various depths so that the well can be
developed in the most economical way. Three of the sensors known in
the art that are used for formation include button resistivity
sensors, density logging sensors, and neutron logging sensors, each
of which will now be described.
[0008] A button resistivity tool includes a number of electrode
buttons, for example three buttons, that are placed into contact
with the borehole wall. One of the buttons injects an electrical
current into the formation, and the potential difference is
measured between the other two buttons. The potential difference is
related to the resistivity of the formation. Button resistivity
tools are described with more detail below in the discussion of
measurement-while-drilling applications.
[0009] A density logging tool uses back scattered radiation to
determine the density of a formation. A typical density logging
tool is described in U.S. Pat. No. 4,048,495, issued to Ellis, nd
is shown in FIG. 2. The density logging tool 20 is shown disposed
in a borehole 3 on a wireline 10. The tool 20 includes a caliper 26
that positions the tool 20 so that the source 24 and sensors 21, 22
of the tool 20 are pressed into the mud-cake layer 23, as close as
possible to the borehole wall 12.
[0010] The density logging tool 20 contains a gamma ray source 24,
typically Cesium-137, that emits medium energy gamma rays into the
formation. The source 24 is enclosed in shielding 26 that shields
the detectors 21, 22 from gamma rays coming directly from the
source 24. The front face 29 of the tool includes a window 25 that
enables a collimated beam of gamma rays to be transmitted into the
formation 2. Through a process called "Compton scattering," the
gamma rays scatter back into the borehole and into the detectors
21, 22.
[0011] Compton scattering is the interaction of a gamma ray with
electrons. When a gamma ray interacts with an electron, it imparts
part of its energy to the electron, and the gamma ray changes
direction. Through one or more Compton scattering events, gamma
rays can be scattered back into the borehole. The number of
scattering events that occur depends on the density of electrons in
the material into which the gamma rays are transmitted. Because the
density of electrons depends on the density of the material, a
density logging tool can measure the density of a formation by
measuring the number of gamma rays that are back scattered in the
formation and return to the borehole where they can be detected by
the tool.
[0012] A typical density logging tool 20 contains two gamma ray
detectors, a short-spaced detector 22, and a long-spaced detector
21. The long-spaced detector 21 is located about 36 cm from the
source 24. Because of the distance between the source and the
long-spaced detector 21, the long-spaced detector receives gamma
rays that are mostly scattered deep in the formation 2. Further,
the front face 27 of the density tool has a window 28 over the
long-spaced detector 21. The window 28 is shaped to collimate the
gamma rays so that those gamma rays that are received in the
detector 21 are even more likely to have scattered relatively deep
in the formation 2 and not the mud-cake layer 23. Even with the
location of the long-spaced detector 21 and the collimating window
28, the density computed by the long-spaced detector 21 is still
affected by the density of the mud-cake layer 23, which the gamma
rays must pass through twice. Thus, the density value computed from
the long-spaced detector 21 is strongly affected by the density of
the mud-cake layer 23.
[0013] The density measured by the long-spaced detector 21 can be
corrected using the short-spaced detector 22, which is typically
located about 11 cm from the source. The short-spaced detector 22
receives back scattered gamma rays that have scattered in materials
close to the borehole wall 3, like the mud-cake layer 23. Again, a
window 29 in the front face 27 of the tool 20 collimates the
incoming gamma rays so as to increase the chance that detected
gamma rays were scattered in the mud-cake layer 23. By combining
the measurements of the two detectors 21 and 22, a corrected value
for the formation density can be computed, as is known in the
art.
[0014] A neutron logging tool makes a measurement corresponding to
the porosity of a formation. A typical neutron logging tool is
disclosed in U.S. Pat. No. 4,035,639 issued to Boutemy et al. A
neutron logging tool contains a neutron source, typically an
Americium-Beryllium source, and a neutron detector. The source
emits high energy neutrons, also called "fast" neutrons, into the
formation. The fast neutrons lose energy as they collide with atoms
in the formation, eventually becoming slow neutrons, also called
"thermal" neutrons. Thermal neutrons will randomly migrate in the
formation. Some of the migrating thermal neutrons will migrate back
into the borehole. A neutron logging tool detects the thermal
neutrons that randomly migrate back into the borehole.
[0015] Hydrogen atoms, with an atomic number of one, have
approximately the same mass as a neutron. Because of their similar
mass, a neutron loses much more energy in collisions with hydrogen
atoms than it does in collisions with any other atom. Thus, the
rate at which fast neutrons become thermal is related to the number
of hydrogen atoms in the moderating material. As a result, the
number of thermal neutrons detected by the neutron logging tool is
related to the number of hydrogen atoms in the formation. Because
water and hydrocarbons have a similar amount of hydrogen atoms, the
neutron logging tool measures how much of the formation is occupied
by water and hydrocarbons. In non-gas bearing formations, a
measurement from a neutron logging tool is related to the
formation's porosity.
[0016] FIG. 3 shows a wireline neutron logging tool 30. A source 31
is located in the tool 30 surrounded by shielding 32. The example
neutron logging tool 30 in FIG. 3 shows two detectors, 33 and 34,
that are used to detect thermal neutrons and ultimately to
calculate the formation porosity. The two detectors 33, 34 are
spaced apart on the neutron logging tool 30. Using the known
spacing of the detectors, a ratio of the count rates can be used to
correct the porosity calculation for borehole shape effects.
[0017] The neutron logging tool 30 also includes a caliper 35 that
serves two purposes. First, it pushes the source 32 and sensors 33,
34 into the opposite face 12 of the formation 2. Second, the
distance that the caliper 35 extends to the wall 36 can be added to
the tool size to compute the borehole diameter, which affects the
neutron measurement.
[0018] To improve on the formation evaluation by wireline tools,
well logging tools can be disposed on a drill string and
measurements can be made while drilling. Such measurements are
called measurement-while-drill- ing ("MWD"), or
logging-while-drilling ("LWD"). In MWD, sensors are disposed on the
drill string and used for formation evaluation during drilling
operations. MWD enables formation evaluation before the drilling
fluid ("mud") invades the drilled formation and before a mud-cake
layer is formed on the borehole wall.
[0019] FIG. 4 shows a prior art drilling system with an MWD tool
42, as disclosed in U.S. Pat. No. 5,339,036 issued to Clark et al.
A drilling rig 40 is positioned over a bore hole 3 that is drilled
into an earth formation 2. Typically, sensors are located in subs
41 that are positioned a few feet above the drill bit 43 on the
drill string 44. In that position, the sensors can evaluate the
formation 2 before significant invasion of the formation by the
drilling fluid takes place.
[0020] Drilling fluid 45 is pumped down through the drill string 44
and ejected through ports in the drill bit 43. The drilling fluid
45 is used to lubricated the drill bit 43 and to carry away
formation cuttings, but it also can interfere with formation
evaluation. Because of the hydrostatic pressure of the drilling
fluid 45 at the drilling depth, the drilling fluid 45 seeps into
the formation 2. This process is called invasion. Sensors on a
wireline tool (as shown in FIGS. 2 and 3) can be moved through the
borehole only after drilling is stopped and the drill bit and drill
string have been removed from the borehole. Often, the drilling
fluid is pumped out of the borehole before a wireline tool is used.
Wireline tools are often affected by the properties of the drilling
fluid 45 that has invaded the formation 2. By disposing sensors in
a sub or MWD collar 41 and performing formation evaluation while
drilling, the measurements can be made before there is significant
invasion, thereby enabling more accurate measurements.
[0021] FIG. 5 shows a cross-section of a MWD collar 50 on a drill
string 44. The collar 50 surrounds the drill pipe 44. A button
resistivity tool is disposed in the drill collar 50. Three button
electrodes 53, 54 and 55 are shown on a blade 56 that extends
radially from the collar 51. The blade 56 places the electrodes 53,
54, and 55 in contact with a borehole wall (not shown in FIG. 5),
enabling accurate formation evaluation. One of the electrodes
injects a electrical current into the formation, while the other
two electrodes measure the potential difference between them. The
measured potential difference and the distance between the two
measuring electrodes are related to the formation resistivity.
[0022] By way of example only, electrode 53 in FIG. 5 could be used
as the injecting electrode. Electrodes 54 and 55 would measure the
potential difference that exists between them.
[0023] Even using MWD, however, there is still some invasion of the
mud filtrate into the formation that causes errors in the
measurements. Because the drilling fluid is pumped through ports in
the drill bit, the formation is exposed to the drilling fluid for
the time it takes the drill to penetrate the distance between the
bit and the MWD collar. Many of these errors can be avoided if the
sensors are disposed in the drill bit itself, thereby enabling the
formation to be evaluated at, and even ahead of, the point where
drilling is occurring.
[0024] One example of a drill bit with integral sensors is
disclosed in U.S. Pat. No. 5,475,309 to Hong et al. FIG. 6 shows a
drill bit 61 with an integral sensor 60. Sensor 60 is a dielectric
tool that measures the water content of the formation near the
drill bit. The sensor 60 can evaluate the formation 2 at the
drilling depth 62, before the formation 2 is penetrated by the bit
60. A sensor 60 disposed in the drill bit enables more accurate
measurements because the formation is evaluated before any
significant invasion of drilling fluid into the formation 2.
[0025] Another drill bit with integral sensors is shown in FIG. 6B,
as disclosed in U.S. Pat. No. 5,813,480 issued to Zaleski, Jr., et
al. FIG. 6B shows a three cone drill bit 68 with temperature
sensors 65 located in the journal 67. The temperature sensors 65
transmit data to a telemetry or data storage system by way of a
wire 68 that runs through the journal 65 and the bit body 66. If
the temperature in the journal begins to rise and exceed normal
operating conditions, that is a signal that the journal bearings
are beginning to fail. Corrective steps, like replacing the drill
bit, can be taken before a catastrophic failure occurs.
SUMMARY OF INVENTION
[0026] One aspect of the invention relates to a drill bit with a
bit body adapted to be coupled to a drill string. The bit body also
has a sensor disposed therein. A single journal is removably
mounted to the bit body, and a roller cone is rotatably mounted to
the journal. In some embodiments, the bit body also includes a
box-end connection.
[0027] Another aspect of the invention relates to a bit body
comprising a box-end connection on one end of the bit body and a
journal connection on an opposite end from the box-end connection,
the journal connection adapted to receive a removably mounted
journal. The bit body includes a sensor mounted therein.
[0028] Yet another aspect of the invention relates to a drill bit
comprising a bit body adapted to be coupled to a drill string, a
single journal removably mounted to the bit body, a temperature
sensor disposed in the single journal, and a roller cone rotatably
mounted on the single journal. In some embodiments, the drill bit
includes a sensor disposed in the bit body.
[0029] Another aspect of the invention relates to a drill bit
comprising a bit body, at least one sensor disposed in the bit
body, a short-hop telemetry transmitter disposed in the bit body,
and a box end connection adapted to connect the drill bit to a
rotary steerable system. The drill bit in this aspect of the
invention also includes a single journal removably mounted to the
bit body and a roller cone rotatably mounted on the journal.
[0030] Yet another aspect on the invention relates to a drill bit
comprising a bit body, a box-end connection adapted to connect the
drill bit to a drill string, and a sensor disposed in the bit
body.
[0031] Other aspects and advantages of the invention will be
apparent from the following description and the appended
claims.
BRIEF DESCRIPTION OF DRAWINGS
[0032] FIG. 1A shows a prior art single cone drill bit.
[0033] FIG. 1B shows a cross section of a prior art single cone
drill bit.
[0034] FIG. 2 shows a cross section of a prior art density logging
tool.
[0035] FIG. 3 shows a cross section of a prior art neutron logging
tool.
[0036] FIG. 4 shows a cross section of a prior art drilling system
with a measurement-while-drilling tool.
[0037] FIG. 5 shows a cross section of a prior art
measurement-while-drill- ing resistivity tool.
[0038] FIG. 6A shows a cross section of a prior art drill bit with
an integral sensor.
[0039] FIG. 6B shows a cross section of a prior art roller cone
with integral temperature sensors.
[0040] FIG. 7 shows an exploded view of a bit body, a removable
journal, and a roller cone according to one embodiment of the
invention.
[0041] FIG. 8A shows a cross section of one embodiment of a drill
bit according to the invention, having a resistivity sensor mounted
in the bit body.
[0042] FIG. 8B shows a cross section of one embodiment of a drill
bit according to the invention, having a temperature sensor mounted
in the journal
[0043] FIG. 8C shows a cross section of one embodiment of a drill
bit according to the invention, having a density logging sensor
mounted in the bit body.
[0044] FIG. 8D shows a cross section of one embodiment of a drill
bit according to the invention, having a neutron logging sensor
mounted in the bit body.
[0045] FIG. 9 shows a perspective view of a drill bit in accordance
with one embodiment of the invention on a drill string with a
rotary steerable system and a measurement-while-drilling
collar.
DETAILED DESCRIPTION
[0046] FIG. 7 shows an exploded view of one embodiment of the
invention. A removable journal 72 is attached at a lower end of the
bit body 73 with bolts 75. A single roller cone 71 can be rotatably
mounted on the journal 73. A complete drill bit 70 is formed by the
bit body 73, the removable journal 72 attached to the bit body 73,
and a roller cone 71 rotatably mounted on the journal 72.
[0047] In this disclosure, "rotatably mounted" in intended to
indicate that the roller cone is fixed on the journal, but in such
a way that it is able to freely rotate.
[0048] The removable journal 72 can be attached to the bit body 73
by any suitable means. FIG. 7 shows bolts 75 that fasten the
journal 72 in place, although one having skill in the art could
devise other suitable ways to attach a removable journal without
departing from the scope of this invention. The invention is not
intended to be limited by the method of journal attachment.
[0049] The bit body 71 in this embodiment is reusable and can
include various sensors therein, as will be explained below with
reference to FIGS. 8A, 8B, 8C, and 8D. Advantageously, the reusable
bit body 73, and any sensors mounted therein, can be used with more
than one roller cone. Even when the roller cone 71 experiences
failure or wears to the point that it must be replaced, the bit
body 73, and any sensors mounted therein, can be reused by removing
the journal 72 and the roller cone 71 and attaching a new journal
and roller cone. The reusable bit body 73 provides for an
economical deployment of sensors, because the bit body 73 and any
sensors mounted therein can be used with a plurality of different
drill cones. This deployment of the sensors saves the cost of
having to replace the bit body having sensors still well within
their life cycle, because the roller cone of bearing journal has
worn out or failed.
[0050] Another element of a bit in accordance with one aspect of
the invention, also shown in FIG. 7, includes a reusable bit body
73 with a box end connection 76. Instead of the typical male
threaded connection at the upper end of the bit body (shown at
element 14 in FIG. 1), the bit body 73 according to this aspect of
the invention has a female box-end connection 76. That is, the
lower end of the drill string has a connection (not shown) that is
threaded into the bit body 73. The box-end connection 76 is located
on the bit body 73 on the end opposite from the removable journal
72.
[0051] FIG. 8A shows the box-end connection 76 in a cross section
view. A threaded connection on the drill string (not shown) is
inserted into the box-end 76 of the bit body 73 at 81. FIGS. 8A-8D
also show a mud channel located in the bit body 73 that delivers
drilling fluid from the drill string, through the bit body 73,
through the journal 72, so the drilling fluid can be discharged
near the roller cone (not shown in FIGS. 8A-8D).
[0052] Advantageously, the box-end connection 76 according to this
aspect of the invention provides for more space in the bit body 73
to locate additional sensors. The added space gained with a box-end
connection also enables the bit body to be adapted to house
measurement devices that require spacing of sensor components for
proper operation. Such devices include the density and neutron
devices described on the foregoing Background section, where the
sensor components require spacing from a source for proper
operation and depth of investigation.
[0053] FIG. 8A shows another aspect of the invention, wherein the
bit body 73 includes sensors used for MWD. Resistivity buttons 811,
812, and 813 are disposed in bit body to measure the resistivity of
a formation. The resistivity buttons can operate the same as those
disclosed in U.S. Pat. No. 5,339,036 issued to Clark et al., as
described in the foregoing Background section. Advantageously, the
single roller cone bit body allows the resistivity buttons mounted
therein to be in contact with the borehole wall, where, as can be
seen in FIG. 6B, the shirttail 66 of a three cone bit trails away
from the borehole wall.
[0054] Here, in FIG. 8A, the buttons 811, 812, and 813 are
connected, via a wire 802, to a short-hop telemetry device 801. The
short-hop telemetry device 801 is located in the bit body 73. It
receives signals corresponding to the resistivity measured between
the buttons 811, 812, and 813 and transmits the signals via a radio
frequency to a telemetry or a receiver having a data storage unit
located further up on the drill string.
[0055] The short-hop telemetry device 801 shown in FIG. 8A may be
any of a number of devices known in the art. For example, the drill
bit could include a data storage device, which stores the
measurement until the tool is removed from the hole, instead of a
short-hop telemetry device. Further, a data analysis device may be
used. A data storage, analysis, or telemetry system will be
described below in the section regarding rotary steerable systems
and MWD collars.
[0056] FIG. 8B shows a cross section of yet another embodiment of
the invention. The removable journal includes temperature sensors
821. The temperature sensors 821 monitor the temperature of the
journal for temperature spikes that might indicate a bearing
failure. In this embodiment, the bit body 73 has a connector 822
that is adapted to connect with wires 823 in the removable journal
73. The connector 822 is in turn connected to the short-hop
telemetry device 801, where the temperature data is transmitted to
a data analysis or storage collar or a telemetry collar.
[0057] FIG. 8C shows a cross section of one embodiment of the
invention where the bit body 73 includes an integral density
logging sensor. The bit body 73 includes a gamma ray source 831.
The bit body itself is used to shield the detectors 832, 833 from
any direct gamma rays, and has a hole 834 to collimate the gamma
rays that are transmitted into the formation 2. A short-spaced
detector 832 is located in the bit body 73, above the source 831.
The long-spaced detector 833 is shown located much higher in the
bit body 73. The box-end connection 76 enables the long-spaced
detector 833 to be located farther away from the source than it
could be in a typical threaded pin bit. The box-end connection 76
enables the long-spaced detector 833 to receive gamma rays
scattered mostly in the formation. The bit body 73 also includes
collimating holes 836 and 837 that collimate the gamma rays
received in the short and long spaced detectors 832 and 833,
respectively. The collimating hole 836 in front of the short-spaced
detector 832 increases the probability that gamma rays received in
the short-spaced detector were scattered in the mud-cake layer 23.
Similarly, collimating hole 837 ensures gamma rays received in the
long-spaced detector 833 were scattered deep in the formation 2.
The source and the detectors can be connected with wires 853.
Advantageously, the box-end connection enables a bit-body with
enough space to house short and long spaced detectors for a density
logging sensor.
[0058] FIG. 8D shows a cross section of one embodiment of the
invention where the bit body 73 includes an integral neutron
logging sensor. A neutron source 841 is located in the bit body 73,
the material of the bit body 73 acts to shield the neutron
detectors 842, 843 from the source 841. One of the neutron
detectors 842 is located in the bit body 73 above the source 841.
The second detector 843 can be located in the box-end connection
76, with enough separation from the first detector 842 so that the
count rates will provide an accurate measurement. The source and
the detectors can be connected with wires 853. Advantageously, the
box-end connection provides the bit-body with enough axial space to
house two neutron detectors.
[0059] Those having skill in the art will realize that other
sensors can be included in the drill bit without departing from the
scope of the invention. The sensors illustrated in this disclosure
may be of particular use in a drill bit, but the invention is not
intended to be limited by the type of sensor. Further, the
invention is not limited to a drill bit with only one sensor. For
example, the journal temperature sensors could be combined in the
same drill bit body with a neutron sensor or a density sensor.
Those having skill in the art will be able to devise other
combinations of sensors to be used in a drill bit, without
departing from the scope if the invention.
[0060] Referring to FIG. 9, the box-end connection 93 used in one
or more embodiments of the invention also enables the drill bit 91
to be mounted closer to a rotary steerable system ("RSS") 92 than a
male threaded (pin) connection would allow. A typical RSS device
includes a looking down pin connection. When both the RSS and the
drill bit have a pin connection, a cross-over sub is required to
connect the RSS and the drill bit. A drill bit with a box-end
connection enables the drill bit to be connected to the RSS without
a cross-over sub.
[0061] The drill string 95 is connected to an RSS 92. The drill
string 44 and the RSS 92 are connected to the drill bit 91 by a
threaded connection 94 on the drill string that is inserted into
the box-end connection 93 on the bit body.
[0062] An RSS device allows an operator to change the direction of
the drill bit, or steer the drill bit, during drilling. By steering
a drill bit, an operator can avoid obstacles, direct the drill bit
to the desired target reservoir, and drill a horizontal borehole
through a reservoir to maximize the length of the borehole
penetrating the reservoir.
[0063] Advantageously, when the drill bit 91 is located closer to
the RSS 92, the torque and vibration created by the RSS 92 are
reduced. This enables the RSS 92 and the drill bit 91 to have
longer operating lives. Further, the reduced torque and vibrations
enables the operator to have better directional control of the RSS
92 and the drill bit 91, resulting in a more accurate well path to
the desired target.
[0064] The combination of sensors mounted in the drill bit and a
bit body with a box-end connection also has advantages. When
sensors are located in the drill bit, they do not have to be
located in a MWD collar above the drill bit. Typically, the MWD
collar would be located behind the drill bit and the RSS, thereby
increasing the distance between the drill bit and the MWD collar.
Because the sensors can be mounted in the drill bit having a
box-end connection, measurements are made at the drilling face,
thereby eliminating some of the interference from the drilling
fluid.
[0065] The advantages of the box-end connection can be gained by
connecting the drill bit with other downhole devices. For example,
it is known in the art to locate drive devices above the drill bit.
Drive devices, such as a positive displacement motor or a mud
turbine, convert the pressure of the drilling fluid into mechanical
rotation. A box-end connection enables the drill bit to be located
closer to such drive devices than with a pin connection.
Advantageously, the vibrations and stresses associated with
transmitting rotational motion to the drill bit are reduced when
the drill bit is located closer to the drive device.
[0066] FIG. 9 also shows an MWD collar 96 located above the RSS 92
on the drill string 44. The MWD collar 96 in this location has a
short-hop telemetry receiver 97 used to receive short-hop data
transmissions from the short-hop transmitter 98 located in the
drill bit 91. The MWD collar 96 can be adapted for several
purposes. The MWD collar 96 can be adapted to analyze the data from
the sensors in the drill bit 91 and make adjustments to the
drilling parameters. Alternatively, the MWD collar 96 can transmit
the data to the surface via "mud-pulse telemetry," or by any other
method known in the art. The MWD collar 96 can also be adapted to
store the data measured by the sensors. One having skill in the art
will realize that the MWD collar 96 can be adapted to perform any
combination of these functions, and any other functions known in
the art, without departing from the scope of the invention.
[0067] While the invention has been described with respect to a
limited number of embodiments, those skilled in the art, having
benefit of this disclosure, will appreciate that other embodiments
can be devised which do not depart from the scope of the invention
as disclosed herein. Accordingly, the scope of the invention should
be limited only by the attached claims.
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